An Artificial Neural Network Approach for Evaluating the Performance of Cyclic Steam Injection in Naturally Fractured Heavy Oil Reservoirs PDF Download
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Author: Ahmet Ersahin
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Book Description
Due to a sharp fall in oil prices in late 2014, many oil exploration companies have either stopped operations or postponed projects to a future date. The resulting slowdown has strengthened the dependency on existing developed fields for oil production. This is a cause of concern for major oil corporations and governments worldwide, as the dependence on mature fields suggests that conventional oil extraction techniques may not be enough to maintain current demand and may lead to significant profit losses. Thus, the development of enhanced oil recovery (EOR) (also known as tertiary recovery) methods to improve recovery from developed fields has attracted attention.Thermal recovery, a widely used EOR method in heavy oil reservoirs, involves the introduction of heat into the formation to reduce the viscosity of the oil in the reservoir. Cyclic steam stimulation (CSS) is an effective thermal process used with naturally fractured reservoirs. The cyclic steam injection (CSI) method incorporates the stages of injecting, soaking and production one by one in a single well.The use of a commercial simulator for estimating production is common. However, the process can be time consuming and complex. Alternatively, it is possible to achieve results within seconds using an adequately trained artificial neural network (ANN).This study analyzes CSI performance based on its effectiveness with respect to viscosity contours and cumulative oil production. Naturally fractured reservoirs are excellent targets for steam injection because they possess a structure where steam can easily diffuse.
Author: Ahmet Ersahin
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Book Description
Due to a sharp fall in oil prices in late 2014, many oil exploration companies have either stopped operations or postponed projects to a future date. The resulting slowdown has strengthened the dependency on existing developed fields for oil production. This is a cause of concern for major oil corporations and governments worldwide, as the dependence on mature fields suggests that conventional oil extraction techniques may not be enough to maintain current demand and may lead to significant profit losses. Thus, the development of enhanced oil recovery (EOR) (also known as tertiary recovery) methods to improve recovery from developed fields has attracted attention.Thermal recovery, a widely used EOR method in heavy oil reservoirs, involves the introduction of heat into the formation to reduce the viscosity of the oil in the reservoir. Cyclic steam stimulation (CSS) is an effective thermal process used with naturally fractured reservoirs. The cyclic steam injection (CSI) method incorporates the stages of injecting, soaking and production one by one in a single well.The use of a commercial simulator for estimating production is common. However, the process can be time consuming and complex. Alternatively, it is possible to achieve results within seconds using an adequately trained artificial neural network (ANN).This study analyzes CSI performance based on its effectiveness with respect to viscosity contours and cumulative oil production. Naturally fractured reservoirs are excellent targets for steam injection because they possess a structure where steam can easily diffuse.
Author: Buket Arpaci
Publisher:
ISBN:
Category :
Languages : en
Pages : 171
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Book Description
Author: Abdolhossein Hemmati-Sarapardeh
Publisher: Gulf Professional Publishing
ISBN: 0128219327
Category : Science
Languages : en
Pages : 510
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Book Description
Chemical Methods, a new release in the Enhanced Oil Recovery series, helps engineers focus on the latest developments in one fast-growing area. Different techniques are described in addition to the latest technologies in data mining and hybrid processes. Beginning with an introduction to chemical concepts and polymer flooding, the book then focuses on more complex content, guiding readers into newer topics involving smart water injection and ionic liquids for EOR. Supported field case studies illustrate a bridge between research and practical application, thus making the book useful for academics and practicing engineers. This series delivers a multi-volume approach that addresses the latest research on various types of EOR. Supported by a full spectrum of contributors, this book gives petroleum engineers and researchers the latest developments and field applications to drive innovation for the future of energy. - Presents the latest research and practical applications specific to chemical enhanced oil recovery methods - Helps users understand new research on available technology, including chemical flooding specific to unconventional reservoirs and hybrid chemical options - Includes additional methods, such as data mining applications and economic and environmental considerations
Author: Ali Shafiei
Publisher:
ISBN:
Category :
Languages : en
Pages : 572
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Book Description
A significant amount of Viscous Oil (e.g., heavy oil, extra heavy oil, and bitumen) is trapped in Naturally Fractured Carbonate Reservoirs also known as NFCRs. The word VO endowment in NFCRs is estimated at ~ 2 Trillion barrels mostly reported in Canada, the USA, Russia, and the Middle East. To date, contributions to the world daily oil production from this immense energy resource remains negligible mainly due to the lack of appropriate production technologies. Implementation of a VO production technology such as steam injection is expensive (high capital investment), time-consuming, and people-intensive. Hence, before selecting a production technology for detailed economic analysis, use of cursory or broad screening tools or guides is a convenient means of gaining a quick overview of the technical feasibility of the various possible production technologies applied to a particular reservoir. Technical screening tools are only available for the purpose of evaluation of the reservoir performance parameters in oil sands for various thermal VO exploitation technologies such as Steam Assisted Gravity Drainage (SAGD), Cyclic Steam Stimulation (CSS), Horizontal well Cyclic steam Stimulation (HCS), and so on. Nevertheless, such tools are not applicable for VO NFCRs assessment without considerable modifications due to the different nature of these two reservoir types (e.g., presence and effects of fracture network on reservoir behavior, wettability, lithology, fabric, pore structure, and so on) and also different mechanisms of energy and mass transport. Considering the lack of robust and rapid technical reservoir screening tools for the purpose of quick assessment and performance prediction for VO NFCRs under thermal stimulation (e.g., steamflooding), developing such fast and precise tools seems inevitable and desirable. In this dissertation, an attempt was made to develop new screening tools for the purpose of reservoir performance prediction in VO NFCRs using all the field and laboratory available data on a particular thermal technology (vertical well steamflooding). Considering the complex and heterogeneous nature of the NFCRs, there is great uncertainty associated with the geological nature of the NFCRs such as fracture and porosity distribution in the reservoir which will affect any modeling tasks aiming at modeling of processes involved in thermal VO production from these types of technically difficult and economically unattractive reservoirs. Therefore, several modeling and analyses technqiues were used in order to understand the main parameters controlling the steamflooding process in NFCRs and also cope with the uncertainties associated with the nature of geologic, reservoir and fluid properties data. Thermal geomechanics effects are well-known in VO production from oil sands using thermal technologies such as SAGD and cyclic steam processes. Hence, possible impacts of thermal processes on VO NFCRs performance was studied despite the lack of adequate field data. This dissertation makes the following contributions to the literature and the oil industry: Two new statistical correlations were developed, introduced, and examined which can be utilized for the purpose of estimation of Cumulative Steam to Oil Ratio (CSOR) and Recovery Factor (RF) as measures of process performance and technical viability during vertical well steamflooding in VO Naturally Fractured Carbonate Reservoirs (NFCRs). The proposed correlations include vital parameters such as in situ fluid and reservoir properties.
Author: Abdolhossein Hemmati-Sarapardeh
Publisher: Gulf Professional Publishing
ISBN: 0128219343
Category : Science
Languages : en
Pages : 462
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Book Description
Thermal Methods, Volume Two, the latest release in the Enhanced Oil Recovery series, helps engineers focus on the latest developments in this fast-growing area. In the book, different techniques are described in addition to the latest technologies in data mining and hybrid processes. Supported field case studies are included to illustrate a bridge between research and practical applications, making it useful for both academics and practicing engineers. Structured to start with thermal concepts and steam flooding, the book's editors then advance to more complex content, guiding engineers into areas such as hybrid thermal methods and edgier technologies that bridge solar and nuclear energy. Supported by a full spectrum of contributors, this book gives petroleum engineers and researchers the latest research developments and field applications to drive innovation for the future of energy. - Presents the latest understanding surrounding the updated research and practical applications specific to thermal enhanced oil recovery methods - Provides an analysis of editors' research on available technology, including hybrid thermal-solvent processes and dual pipe configurations - Teaches about additional methods, such as data mining applications, and economic and environmental considerations
Author: Eric Robert Matus
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Book Description
A novel method to enhance oil production during cyclic steam injection has been developed. In the Top-Injection and Bottom-Production (TINBOP) method, the well contains two strings separated by two packers (a dual and a single packer): the shortstring (SS) is completed in the top quarter of the reservoir, while the long string (LS) is completed in the bottom quarter of the reservoir. The method requires an initial warm-upstage where steam is injected into both strings for 21 days; then the LS is opened to production while the SS continues to inject steam for 14 days. After the initial warm-up, the following schedule is repeated: the LS is closed and steam is injected in the SS for 21days; then steam injection is stopped and the LS is opened to production for 180 days. There is no soak period. Simulations to compare the performance of the TINBOP method against that of a conventional cyclic steam injector (perforated across the whole reservoir) have been made. Three reservoir types were simulated using 2-D radial, black oil models: Hamaca (9°API), San Ardo (12°API) and the SPE fourth comparative solution project (14°API). For the first two types, a 20x1x20 10-acre model was used that incorporated typical rock and fluid properties for these fields. Simulation results indicate oil recovery after 10 years was 5.7-27% OIIP with TINBOP, that is 57-93% higher than conventional cyclic steam injection (3.3-14% OIIP). Steam-oil ratios were also decreased with TINBOP (0.8-3.1%) compared to conventional (1.2-5.3%), resulting from the improved reservoir heating efficiency.
Author: Mohammed Alghazal
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Book Description
The increasing demand for energy and accelerated consumption of hydrocarbon fuel have made it a necessary objective for the oil and gas industry to continuously search for ways to improve and maximize recovery from oil reservoirs, to meet this growing global demand. Water flooding is one of the most common secondary recovery practices used in the petroleum industry to maintain reservoir pressure and improve oil displacement efficiency and recovery. Nonetheless, water flooding could pose several production problems in certain types of naturally fractured reservoirs, jeopardizing the overall sweep efficiency and oil recovery in the field. The presence of these heterogeneous natural fracture systems highly influences and complicates fluid flow process in the reservoir's transport media. These fractures provide easy conduits and fluid pathways for the injected water, causing early premature water breakthrough, excessive water production and rapid decline of oil rate.The implementation of polymer gel treatments is one of the viable solution commonly used in the industry to mitigate sweep conformance problems and improve oil recovery from naturally fractured reservoirs. Water-soluble polymer solutions are combined with cross-linking agents to form an in-situ gel that can be injected with water into the reservoir media. This polymer gel not only improves the overall mobility ratio of injected fluid, but also provides a mean to plug the conduit fractures and subsequently improving overall volumetric sweep efficiency and oil recovery from the reservoir matrix.Reservoir simulators are commonly used to build reliable reservoir models for the purpose of history matching, production forecasting and evaluation of various design scenarios. Nonetheless, reservoir simulation can become very computationally demanding and time- consuming process. This problem could be overcome by the development of Artificial Neural Network (ANN) models that could be used to generate various possible scenarios at a muchefficient time pace compared to reservoir simulation.The main objective of this research is to develop neuro-simulation proxy models for theimplementation of water flooding and polymer gel flooding in naturally fractured reservoirs. Three main ANN models, one forward and two inverses, were developed for each scenario, water flooding and polymer gel flooding.The first ANN, Forward ANN, provides a forward solution to predict the production profiles of oil rate, water cut and recovery factor for a given set of reservoir and design data. Forward results were matched within a desired tolerance of l0%. The second ANN, Inverse ANN- 1, provides an inverse-looking solution to estimate the project design parameters required to produce a given production profile for a given set of reservoir properties. Five design parameters were investigated, including: reservoir's drainage area, injection rate, producer bottom-hole pressure, polymer concentration and cross linker concentration. The last ANN, Inverse ANN-2, can be used as a tool for history matching and estimation of reservoir properties given a production profile and project design parameters. The reservoir properties predicted by this model include: matrix and fracture porosity, matrix and fracture permeability, fracture spacing, reservoir thickness and initial water saturation. The results from inverse ANN models were produced with an average error of 5 to 10%, per design parameter, and an average error of 8 to 28%, per reservoir property. Collectively, a total of six ANN tools were developed for the purpose of this research and were all encapsulated in a user-friendly Graphical User Interface (GUI) environment, to allow the end users for an easy access and utilization of these expert tools.
Author: Mohammad Tamim
Publisher:
ISBN:
Category : Oil fields
Languages : en
Pages : 310
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Author:
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Category :
Languages : en
Pages :
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Oil recovery by steam injection is a proven, successful technology for nonfractured reservoirs, but has received only limited study for fractured reservoirs. Preliminary studies suggest recovery efficiencies in fractured reservoirs may be increased by as much as 50% with the application of steam relative to that of low temperature processes. The key mechanisms enhancing oil production at high temperature are the differential thermal expansion between oil and the pore volume, and the generation of gases within matrix blocks. Other mechanisms may also contribute to increased production. These mechanisms are relatively independent of oil gravity, making steam injection into naturally fractured reservoirs equally attractive to light and heavy oil deposits. The objectives of this research program are to quantify the amount of oil expelled by these recovery mechanisms and to develop a numerical model for predicting oil recovery in naturally fractured reservoirs during steam injection. The experimental study consists of constructing and operating several apparatuses to isolate each of these mechanisms. The first measures thermal expansion and capillary imbibition rates at relatively low temperature, but for various lithologies and matrix block shapes. The second apparatus measures the same parameters, but at high temperatures and for only one shape. A third experimental apparatus measures the maximum gas saturations that could build up within a matrix block. A fourth apparatus measures thermal conductivity and diffusivity of porous media. The numerical study consists of developing transfer functions for oil expulsion from matrix blocks to fractures at high temperatures and incorporating them, along with the energy equation, into a dual porosity thermal reservoir simulator. This simulator can be utilized to make predictions for steam injection processes in naturally-fractured reservoirs. Analytical models for capillary imbibition have also been developed.
Author:
Publisher:
ISBN:
Category : Petroleum
Languages : en
Pages : 1528
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